High Integrity PressureProtection System ( HIPPS)

What’s HIPPS?-- HIPPS --High Integrity Pressure

Protection System

Ø Response to increasing environmental awareness.

Ø Protection against Process over-pressurization.

Ø Approved Alternative to traditional relief systems – Reduce Flare

Ø Reduce OPEX (Relief Valves cost and testing)

Excess uncontrolled pressure in the Process Industry can result in severe threats to human life and the environment when flammable, explosive, hazardous, or toxic chemicals are released to the atmosphere.

HIPPS are installed instead of

conventional mechanical relief valves to handle

high flow rates and high pressures,

reducing the risk of production units exceeding their

design parameters. It is a system of

protection against high pressure & flow situations that leads

dangerous processes to a

predictable & safe state in a very short

time.

International standards - API 521, Code Case2211 of the ASME Section VIII, Division 1 and 2,ANSI/ISA 84.01-2004, IEC 61511 - are now inplace to allow for the application of highreliability safety instrumented systems toreplace traditional mechanical relief devicesand to remove the need for flaring.

The evolution of High Integrity PressureProtection System (HIPPS) has thereforeradically reduced the need for traditionalmechanical relief devices and the level offlaring in oil and gas applications.

Where canHIPPS be used?

• Long-distance connection of a highpressure marginal reservoir with existing surface facilities.

• High pressure well connected to a low pressure flow line.

• Protection of flexible risers against high pressures (Floating Structures)

Applications:

• Wellhead flowline

• Pipeline and compressor stations

• Flaring systems

• Separation and Processing Facilities

• Gas plants

• Gas storage

• Floating production storage and

offloading (FPSO) vessels

• Offshore platforms

• Onshore operations

REDUNDANCY:• 2oo3 Pressure Transmitters• Isolators to DCS (trip & deviation alarms)• 2oo3 Relays• 1oo2 Block valves with 2oo2D-SOV

TESTS:• Transmitters and relays arround 5 years.• 1 Solenoid for 1 month and partial stroke test• 5 year complete test

PERFORMANCE:• SIL 3• > 200 Year MTTF spurious trips

HIPPS Technical Specifications

SIMPLE OR DOUBLE VALVE, MOUNTED ON SKID OR INDEPENDENT, PNEUMATIC,

HYDRAULIC OR LINE GAS.

• Severe Operating Conditions• Safety Critical Operations• Reliability in remote locations

"All these factors are key concerns for the oil and gas equipment used in

upstream, intermediate and downstream processes. Control valves

are a crucial necessity for absolute closure and reliable pressure and flow

control”.

A HIPPS is designed and built in accordance with IEC 61508 and IEC 61511

standards. These international standards

refer to Safety functions and instrumented safety

systems

A HIPPS system protects site personnel, the general public and the environment, in addition to valuable production assets.

Operating conditions:

Applicability:

Pressure ranges: up to 20,000 psi Temperature: -50 - 1400 ° FSizes: 2 to 36 inches

Torch systemsReplacement of relief systemsWellhead Flowline ProtectionPipe and compressor stationsGas Plant / Gas StorageOffshore PlatformsOnshore OperationsFloating Storage Ships and discharge of fuelsEmergency Shut Down systemsOverpressure Protection Systems

HIPPS Justification and Benefits

Improvement over Mechanical relief devices based on:

• Environmental considerations.• Increased Safety, identifying and mitigating the overpressure risk.• Project costs reduction (safety relief valves, flares, downstream process line

ratings).• Reduction or elimination of the flare (little or no hydrocarbon in the flame).• Removal of safety valves (API 521, ASME Code Case 2211, ANSI / ISA 84.01-2004,

IEC 61511)• Easier to operate, practical system. • Offshore Platform weight savings: No need for flare or safety relief valves, pipe

rating reduction.• Increased flexibility, increase operating pressure, performance and production.• Increased diagnostics and reduced downtime (fault location, reset and continuous

production).• False trips reduction.

• Gas burning reduction.• Less Capital Expenditure.• Less Operational Expenses.• Less False Trips.• Free valuable real estate for Offshore installations.

Benefits

Justification

Standards

• Until August 1996, ASME required the installation of pressure relief devices.• In Code Case 2211, ASME recognized that overpressure protection should be

provided by the most appropriate engineering option.• The use of HIPPS can be used but should result in an installation that is

equally safe or safer than the conventional design.• The proposed HIPPS is independent of the possible causes of overpressure;

It is as reliable as the pressure relief device it is replacing; And is able to fully mitigate an overpressure event.

Background

International standards to allow the application of highly reliable instrumented safety systems (SIS) to replace traditional mechanical relief devices are:

• API 521• Case Code 2211 of ASME Sección VIII,

Division 1 and 2• ANSI / ISA 84.01-2004• IEC 61511

HIPPS Guidelines

• IEC 61508 defines specific guidelines for developing the SIS for risk reduction.• IEC 61511 defines the applications of the process sector that provides guidance for the

implementation of the SIS in the process industries.• These documents govern the development of a HIPPS (like specialized SIS) in applications

for the protection of pressure of overpressure.• These international standards govern the HIPPS design and define the level of safety

integrity (SIL) required for the HIPPS

The application of these new standards and the later development of the SIS technology have allowed the application to replace the

mechanical devices:

• The reduction of risks required, results from the need to have SIS security systems with high availability and reliability.

Higher-4

2 2 2 3 NA NA

Meaningful-3

1 1 2 2 3 NA

Moderate-2

NR 1 1 2 2 3

Less than-1

NR NR NR 1 1 2

L M H(2)

Occasional(3)

Probable(4)

Frequent(1) Remote

riesgo

SIL Assignment Matrix to Determine the SIL level to be assigned.

NS = Not suitable; Additional safeties are required.

NR = Not required; SIF most likely not necessary.

FRECUENCY

The SIS standards cover a variety of techniques for determining SIL requirements; Risk Matrix, Risk Graph and LOPA (layers of protection analysis) are techniques that are considered to determine the level of risk for protection by the SIS system.

SE

VE

RIT

YRisk Matrix Example

HIPPS Architecture

S

Block Valve 1 Block Valve 2

Vent Vent

HIPPS Logic Solver

Skid HIPPS

Logic Solver

Skid HIPPS

• Experience.• Responsibility of a single source.• Compliance with the IEC 61508.• 34 Systems (68 Valves) currently in operation.• Zero Failures.• Continuation of R+D.• Complete documentation package.• Fully functional supplied slip system (Plug & Play).• Piggable design.• Integration of systems with other suppliers (Measurement,

wellheads)• Commisioning and Start-Up Services.• Worldwide Support / Field Service.

Why TRAC?

Conclusions

• Under the new regulations, a special SIS called HIPPS can be applied instead of traditional mechanical relief devices.

• A risk assessment is conducted to determine the SIL requirement for the HIPPS system.

• A properly applied HIPPS system mitigates the risk of overpressure of the system safely without the need for the burning of natural hydrocarbon resources and the environmental problems that the burning represents.

• HIPPS Solutions provide direct savings in Capital (CAPEX) and Operational (OPEX) Costs and reduced Space requirements for new and existing Projects.

HIPPS Experience• 2004 – BG – Trinidad

• 2004 – BG / Reliance IND – India

• 2005 – BG – India

• 2005 – 2006 – Chevron – Bangladesh

• 2006 – BG – India (Skid HIPPS)

• 2006 – 2007 – BG – Trinidad

• 2007 – 2008 – BG – Trinidad

• 2008 – Cairn Energy India – India

• 2008 – BG – Trinidad, Platform Hibiscus

• 2009 – BG – Trinidad Dolphin Deep – Trinidad

• 2010 – 2011 – BG – Bolivia, Platform PMO-6

Case StudyBibiyana

The Bibiyana gas field is located at the NE

corner of Bangladesh, at Block 12.

approximately 150 km from the capital of

Dhaka.

The Bibiyana gas field was developed by Unocal in the country of Bangladesh using HIPPS as the first protection system.

The project will be designed for a total capacity of over 600 MMSCFPD. The Bibiyana field will be developed from the drilling of wells in two separate clusters.The southern cluster will contain the main gas processing facilities. The north cluster is located 4 km from the main cluster. Both will produce approx. 300 MMSCFD of total production.

Project description

HIPPS GoalsBibiyana

A HIPPS was selected for the overpressure protection on the pipeline from the North cluster to the South Cluster.

Goals

• Security pressure protection and high reliability.• Remote clusters flame minimization (environment considerations).• Tubing pressure reduction from wellheads API 5000# clasisification.• Burners installation cost reduction.

Application

• HIPPS SIL 3 system located in each flowline for a (7) systems total.• 4 km ofpipeline rated ANSI 600#

Achievements

• Downstream pipeline length reduction.• No burner systems.• No wellhead relief valve.• CAPX savings, more than 2 Million USD.

Bibiyana HIPPS Layout

BontangWest Seno Hub100 MMSCFD

Inlet Gas

Greater Gendalo Hub550 – 650 MMSCFD

Inlet Gas

Greater Gehem Hub300 – 500 MMSCFD

Inlet Gas

Waterdeep Gas Cube

Case StudyBotang LNG

The Bontang LNG plant is the largest in the world, located in eastern Kalimantan, Indonesia.

New gas production from two large offshore fields has been

added to Bontang gas pipelines and facilities for gas

treatment.

These facilities, Gendalo and Gehem-Ranggas, are floating deepwater installations with new individual pipelines that

will feed the existing onshore pipeline system in the Santan

terminal.

Limitations and ConsiderationsBotang LNG

Pressure limitations existing in the pipeline:

1. HP pipelines from Gendalo and

GehemRanggas will supply gas at a

pressure of approximately 1000 psig.

2. The existing piping protection system

could not withstand higher pressures due

to new production.

3. 910 to 940 psig of the pipeline pressure

4. The intake pressure of the Bontang

plant is set at 700 psig.

5. A pipeline protection system must be

used.

1. A full flow relief with a burner would

require a very large burner (600 +

MMSCFD) for each offshore gas

pipeline.

2. Customer determined the most

effective protection of existing pipeline

will be through a HIPPS system.

3. Great reduction of burning to the

atmosphere.

4. Conservation of natural resources.

5. Economic justification through the

reduction of lost revenues and the

Capex of the construction of burner

systems.

Technical Considerations for Pressure Reduction: